Abstract This paper addresses the automatic generation control of deregulated multi area power system including one of the most important renewable energy resource viz. wind power plant. The interconnected two area power system is thermal-hydro system with two GENCOs in thermal area and one GENCO in hydro area. Generation rate constraint (GRC) is considered in all the GENCOs separately. Integral square error technique is used to optimize the gains of various integral controllers. It is seen that system response becomes poorer in terms of peak overshoots and settling time by considering GRC. DISCO participation matrix is chosen on the basis of open market strategy which is continuously changing. So, effect of changing DPM on dynamic responses is studied, following a step load perturbation. It is revealed that there is no effect of changing DPM on system’s dynamic responses. Keywords – Automatic generation control (AGC), deregulated power system, DISCO participation matrix (DPM), wind turbines, generation rate constraint (GRC).

1. IJRET: International Journal of Research in Engineering and Technology eISSN: 2319-1163 | pISSN: 2321-7308
__________________________________________________________________________________________
Volume: 02 Issue: 11 | Nov-2013, Available @ http://www.ijret.org 180
FREQUENCY REGULATION OF DEREGULATED POWER SYSTEM
HAVING GRC INTEGRATED WITH RENEWABLE SOURCE
Aditi Gupta
Department of Electrical & Electronics Engineering, UIET, Punjab University, Chandigarh
aditi_2881@rediffmail.com
Abstract
This paper addresses the automatic generation control of deregulated multi area power system including one of the most important
renewable energy resource viz. wind power plant. The interconnected two area power system is thermal-hydro system with two
GENCOs in thermal area and one GENCO in hydro area. Generation rate constraint (GRC) is considered in all the GENCOs
separately. Integral square error technique is used to optimize the gains of various integral controllers. It is seen that system response
becomes poorer in terms of peak overshoots and settling time by considering GRC. DISCO participation matrix is chosen on the basis
of open market strategy which is continuously changing. So, effect of changing DPM on dynamic responses is studied, following a step
load perturbation. It is revealed that there is no effect of changing DPM on system’s dynamic responses.
Keywords – Automatic generation control (AGC), deregulated power system, DISCO participation matrix (DPM), wind
turbines, generation rate constraint (GRC).
---------------------------------------------------------------------***---------------------------------------------------------------------
1. INTRODUCTION
Automatic generation control (AGC) or megawatt frequency
control involves the problems of transient load perturbations
that make the frequency and tie line power to deviate from
their nominal values. These perturbations also lead to the
mismatch in generation of power system and overall load
demand. But these are the most important parameters of power
system that are needed to be controlled to their nominal values
even after the disturbances [1]. So, synthesis of AGC
controllers is required like integral controllers, proportional
integral controllers, proportional integral derivative (PID)
controllers and fuzzy logic controllers etc. that provide the
secondary control in the overall AGC. Primary control is
provided by governor-turbine speed regulation model only.
Now a days, focus is shifted towards the restructuring of
power system. Initially, a single entity namely vertically
integrated unit (VIU) owned the overall power system
structure but now independent power producers (IPPs) have
evolved and independent organizations like generation
companies (GENCOs), transmission companies (TRANCOs)
and distribution companies (DISCOs) have come up which
generate and sell power at their own regulated rate. There are
no geographical domain restrictions for these companies to
operate [2, 3]. Conventional power plants like thermal, hydro,
nuclear etc pose a threat to the environment and lead to the
global warming due to harmful gas emissions. So, it is of great
importance to include cleaner sources of power into the power
system like solar power, wind power etc. Solar power plants
have low energy conversion efficiency and are more
expensive than wind power plants, so focus is mainly shifted
towards wind power plant [4, 5, 6].
The objective of the paper is to present a two area deregulated
hydro-thermal power system having GRC including wind
power plant. However, with large penetration of wind power
into the power system, the grid frequency will be more
vulnerable to disturbances because wind power converters
mostly do not participate in the frequency regulation or AGC
services. But again in the view of continuous depleting
conventional energy resources, it becomes important to shift
our focus to such non-conventional resources. There are some
advanced techniques like doubly fed induction generators
(DFIG) based wind turbines that support the system inertia
and participate in the overall AGC. But these advanced
techniques are ignored here for time being. The main
objectives of the paper are:
a) To study the effect of changing DPM on the dynamic
responses of the system.
b) To study the effect of GRC on system’s dynamic
responses.
2. SYSTEM UNDER INVESTIGATION
A two area hybrid deregulated power system as shown in Fig.
1 is considered as a test system to study the AGC problem. An
interconnected hybrid system comprising of thermal-hydro-
wind has been used for simulation studies.

2. IJRET: International Journal of Research in Engineering and Technology eISSN: 2319-1163 | pISSN: 2321-7308
__________________________________________________________________________________________
Volume: 02 Issue: 11 | Nov-2013, Available @ http://www.ijret.org 181
1
1+sTg1
2
B
2πT
s
1
1+sTg2
1
B
11
1
R
12
1
R
Pw
P
∆PD1
∆PD2
Turbine
1
1+sTt1
1
1+sTt2
Turbine
-T s+1w
1/2T s+1w
Reheater
1+sK Tr1 r1
1+sTr1
1+sK Tr2 r2
1+sTr2
GENCO3 (hydro)
GENCO2 (thermal)
GENCO1 (thermal)
df1
df2
Kp1
1+sTp1
Cpf11
Cpf21
Cpf31
Cpf33Cpf23Cpf13
Cpf32
Cpf22
p.u. load of DISCO3
p.u. load
of
DISCO2
p.u. load
of
DISCO1
12
apf
+
12
a
+
i2K
s
+ +
+
i1K
s
+
+
+
Governor
_
_
11
apf
+
+
_
2
apf
2
1
R
+
+
_
_
+
+
+
+
+
+
+
+
+
+
+
+
+
Cpf12
+ _
_ _
12
a
+
Kp2
1+sTp2
2
d p i
2
d p 2 i
K s +K s+K
K s +K +f /R s+K
Electric governor
GRC
GRC
GRC
Fig.1 Two area hydrothermal deregulated system having GRC including wind turbine.

3. IJRET: International Journal of Research in Engineering and Technology eISSN: 2319-1163 | pISSN: 2321-7308
__________________________________________________________________________________________
Volume: 02 Issue: 11 | Nov-2013, Available @ http://www.ijret.org 182
Area1 is thermal system and has two GENCOs each equipped
with reheat turbine and area2 is a hydro system having one
GENCO equipped with electric governor. GRC is added in
each of the GENCOs separately. It is 3%/minute for thermal
units. For hydro units, it is 270%/minute (maximum limit) and
360%/minute (minimum limit) [2]. In addition to thermal and
hydro plants, fixed speed wind power plant is also integrated
into the each area of the system. Wind speed varies with time
and is related to the wind speeds of the previous time [7]. In
this paper, it is considered that the output power of wind
generators depends on the wind speed at that time. The output
power of wind turbine Pw is calculated as:
Pw = 0, Vs < Vi and Vs > Vo
Pw = Pwr*[(Vs-Vi) / (Vr-Vi)], Vs ≥ Vi and Vs ≤ Vr
Pw = Pwr, Vs ≥ Vr and Vs ≤ Vo
Where Vi, Vr and Vo are the cut-in wind speed, rated wind
speed and cut-out wind speed respectively. Their values are
taken as 5, 15, 45 m/s respectively. Vs is wind speed at any
instant. Pwr is the rated power output of wind turbine.
Simulation model has been developed in MATLAB 7.0 to
obtain dynamic responses for various parameters for different
step load perturbations (1% or 2%) in each area or in both the
areas. The power system parameters used in the model are
given in appendix. The optimum values of integral controller
gains have been found using ISE technique, considering step
perturbation in any one area, keeping all other areas
uncontrolled. The objective function (cost function) J for ISE
technique [6] is
J =  [df1
2
+ df2
2
+ dPtie
2
] dT
Where,
dT = small time interval during sample
df1 & df2 = incremental change in frequency of area1 & area2.
dPtie = incremental change in tie line power of area.
In the control application, we use integral method to decrease
the rise time and reduce the steady state error. The speed
changer setting can be adjusted automatically by monitoring
the frequency changes. The signal fed to the integral controller
is called ACE (area control error). The integrator output, thus
the speed-changer position, attains a constant value only when
the frequency error has been reduced to zero.
3. EFFECT OF DPM
In deregulated environment, DPM is chosen on the basis of
open market strategy [3, 8]. As the market strategy changes
every day, so is the DPM. So it becomes important to see the
effect of changing DPM on the dynamic responses of the
system involving wind power plant. Also, controllers are to be
optimized for different DPMs, again using ISE technique.
Table I shows the optimized values of integral controller gains
and electric governor parameters for the following two DPMs:
0.6 0 0.3
DPM = 0 0.7 0.3A
0.4 0.3 0.4
 
 
 
 
B
0.5 0.8 0.5
DPM = 0.5 0.1 0.3
0 0.1 0.2
 
 
 
 
Table 1 Optimized Value of Various Gains
DPM Electric Governor
Parameters
Integral
Controller Gains
Kd Kp Ki Ki1 Ki2
A 3.6 3.3 4.6 0.472 0.041
B 1.2 3.4 3.1 0.3435 0.044
Fig.2 Dynamic responses comparison for sets of DPMs
In present system, area contro error (ACE) participation
factors i.e (apfs) are chosen as follows:
 For thermal area, the apf of GENCOs are
proportional to their respective generations. So,
apf11 = Pg1/ (Pg1+Pg2)
and apf12 = Pg2/ (Pg1+Pg2)
 For hydro area, apfs of various GENCOs are
considered to be equal. So,
apf2 = 1
Analysis: The two sub-figures of Fig. 2 show the dynamic
response comparison of df1 and dPtie for two DPMs
corresponding to their respective optimum gains from Table 1.
0 20 40 60 80 100 120 140 160 180 200
-15
-10
-5
0
5
10
15df1(Hz)
0 20 40 60 80 100 120 140 160 180 200
-0.5
0
0.5
1
time (s)
dPtie(pu)
DPM(A)
DPM(B)
DPM(A)
DPM(B)

4. IJRET: International Journal of Research in Engineering and Technology eISSN: 2319-1163 | pISSN: 2321-7308
__________________________________________________________________________________________
Volume: 02 Issue: 11 | Nov-2013, Available @ http://www.ijret.org 183
From the figures, it is clear that there is hardly any difference
in the responses when different DPMs are considered with
their respective optimum controller gains. However, the
optimum gains corresponding to different DPMs are quite
different.
4. EFFECT OF GRC
It is more realistic to add the physical constraints in the power
system. One such constraint is GRC. Fig. 3 shows the
comparison of dynamic responses with and without GRC for
deregulated wind integrated power systems.
Fig 3 Dynamic responses comparison in terms of GRC
Analysis: Various sub-figures of Fig. 3 show the comparison
of dynamic responses in terms of GRC. It is clearly seen that
the responses become poorer in terms of overshoots and
undershoots and settling time. But it is the more practical way
to include GRC into the power system.
CONCLUSIONS
Frequency is one of the most important parameter to
determine the stability of a system. To improve the overall
dynamic performance in the presence of the plant parameters
changes and system non linearities, the conventional integral
controller based AGC problem has been formulated as an
optimization problem based on system performance index ISE
for multiple operating conditions. Wind power plant is
included in the system for taking care of continously
increasing load demands and in the view of depleting
conventional energy resources. The overall power plant is
analysed in deregulated or restructured scenario. Transient
responses hardly vary for varying DPM in terms of peak
deviations (overshoots and undershoots) and settling time. The
AGC system balances it well in terms of frequency deviations
and tie line power deviations. So, any DPM can be chosen
based on the market economy. It is also analysed that although
the responses become poorer in terms of peak deviations
(undershoots and overshoots) and settling time, it is more
realistic and practical appraoch to include GRC in the system.
APPENDIX
The various system parameters and their description in given
in Table 2
Table 2 System Parameters
Name Description Value
Pr1, Pr2 Rated power 2000MW
Tg1, Tg2 Speed governor time
constant
0.08 sec
Tt1, Tt2 Steam turbine time
constant
0.3 sec
Kr1, Kr2 Reheater gain 0.5
Tr1, Tr2 Reheater time constant 10 sec
Kp1, Kp2 Power system gain 60 Hz/puMW
Tp1, Tp2 Power system time
constant
20 sec
B1, B2 Frequency bias constant 0.4249
R11, R12, R2 Speed regulation
parameter
2.4 Hz/puMW
a12 - Pr1/Pr2 -1
Tw Water time constant 1 sec
T Synchronizing time
constant
0.0866puMW/rad
∆PD1, ∆PD2 Step load perturbation Can be varied
Pwr Rated wind power output 1 pu
f Nominal frequency 60 Hz
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0 20 40 60 80 100 120 140 160 180 200
-20
0
20
df1(Hz)
0 20 40 60 80 100 120 140 160 180 200
-20
0
20
df2(Hz)
0 20 40 60 80 100 120 140 160 180 200
-1
0
1
time (s)
dPtie(pu)
With GRC
Without GRC
With GRC
Without GRC
With GRC
Without GRC

5. IJRET: International Journal of Research in Engineering and Technology eISSN: 2319-1163 | pISSN: 2321-7308
__________________________________________________________________________________________
Volume: 02 Issue: 11 | Nov-2013, Available @ http://www.ijret.org 184
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